Market Overview

Southwestern Energy Announces Second Quarter 2018 Results

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Raises full year 2018 production guidance with no increase to capital
investment guidance Expects portfolio to generate modest free cash flow
in 2018

Southwestern Energy Company (NYSE:SWN) today announced its second
quarter financial and operating results. Unless noted, results are
compared to the second quarter of 2017.

"This quarter's strong performance reflects increased margins, improved
capital efficiency, and higher production growth," said Bill Way,
President and Chief Executive Officer of Southwestern Energy. "Our
strategy of delivering growing value from our high-return Appalachia
assets, and shift towards greater liquids while achieving greater
operational efficiencies, are creating enhanced returns for our
shareholders. This is underscored by our assets' projected ability to
generate modest free cash flow in 2018 without raising capital guidance."

Second Quarter Highlights

  • Generated net cash provided by operating activities of $300 million
    and net cash flow of $280 million, up 13% and 12%, respectively
  • Delivered on previously announced cost initiatives, saving over
    $110 million annually (beginning in 2019) through G&A and interest
    reductions
  • Realized NGL and oil pricing, including hedges, of $15.05 and
    $59.22 per barrel, up 34% and 46%, respectively
  • Increased margins in Southwest Appalachia by 76% to $1.60 per Mcfe
  • Exceeded production guidance, reporting net production of 234 Bcfe,
    up 5%
  • Delivered a 19% increase in Appalachia Basin net production of 167
    Bcfe or 1.8 Bcfe per day, including 20% liquids production
  • Produced 44% higher natural gas liquids and oil of 61,370 barrels
    per day
  • Improved well development efficiency driven by leading operational
    execution, completing 56 wells, 13 ahead of original development plan
  • Added extended lateral inventory in the Tioga development area
    through a joint development arrangement
  • Reported net income attributable to common stock of $51 million, or
    $0.09 per diluted share, and adjusted net income attributable to
    common stock of $105 million, or $0.18 per diluted share

Full Year Update

  • Maintaining full-year $1.15 - $1.25 billion capital investment
    guidance; second quarter capital investment of $403 million,
    consistent with front end loaded plan
  • Expecting existing portfolio to generate modest cash flow above
    full year capital investment at current prices, with any excess cash
    applied to outstanding borrowings on the revolving bank facility
  • Raising net production guidance to 955 - 970 Bcfe, up from 930 -
    965 Bcfe (see Production Guidance table below)
  • Increasing Appalachia Basin net production guidance to 695 - 707
    Bcfe, up 21% (based on midpoints) compared to 2017

The Company will invest within its original full-year capital investment
guidance of $1.15 to $1.25 billion. Capital investment for the second
quarter totaling $403 million was consistent with the Company's planned
capital program, including $311 million related to drilling and
completion operations, primarily in the Appalachia Basin. Improved
operational efficiency gains and successful operational execution have
positively affected the pace of activity. The Company has been able to
accelerate completion of an additional 13 wells in the second quarter
compared to the original plan, which will result in a production benefit
throughout the year. The Company now expects to be toward the high end
of its total 2018 well count guidance of 105 to 125 completed wells. The
Company is progressing its previously announced water project in
Southwest Appalachia, which is expected to be operational by year end
with the majority of the capital to be invested during the second half
of the year.

The Company is raising full-year net production guidance to 955 - 970
Bcfe, driven by liquids growth in Southwest Appalachia and production
improvements in Northeast Appalachia. In Southwest Appalachia, the
Company continues to focus on liquids production and has raised total
NGL and oil barrels guidance by 5% (based on midpoints), or 2,700
barrels per day, compared to original guidance. Northeast Appalachia
production is expected to increase by 15 Bcf (based on midpoints) due to
the continued benefit from well outperformance, operational execution
and gathering capacity improvements.

Production Guidance (1)

                   
1st Quarter 2nd Quarter 3rd Quarter 4th Quarter Total Year
Guidance:
Natural Gas (Bcf) 197 201 213 – 218 210 – 217 821 – 833
NGLs (MBbls) 4,230 4,862 4,900 – 5,100 5,250 – 5,400 19,242 – 19,592
Oil (MBbls) 613 723 900 – 1,000 900 – 1,000 3,136 – 3,336
Total Production (Bcfe) 226 234 248 – 255 247 – 255 955 – 970
Total Production (MMcfe/d) 2,511 2,571 2,696 – 2,772 2,685 – 2,772 2,616 – 2,658
 
Full-Year Production by Division Production
(Bcfe)
Northeast Appalachia 459 – 465
Southwest Appalachia 236 – 242
Fayetteville Shale 260 – 263
Total 955 – 970
    (1)   Consistent with original guidance, the updated guidance excludes any
impact from Fayetteville strategic alternatives announced in
February 2018.
 

Second Quarter 2018 Financial Results

               
FINANCIAL STATISTICS (Unaudited) For the three months For the six months
ended ended
June 30, June 30,
2018 2017 2018 2017
Financial Results (in millions, except per share amounts)
Net income attributable to common stock $ 51 $ 224 $ 257 $ 505
Adjusted net income attributable to common stock (non-GAAP measure) $ 105 $ 40 $ 267 $ 127
Adjusted EBITDA (non-GAAP measure) $ 317 $ 281 $ 713 $ 631
Net cash provided by operating activities $ 300 $ 266 $ 664 $ 578
Net cash flow (non-GAAP measure) $ 280 $ 250 $ 638 $ 568
Total capital investments $ 403 $ 325 $ 741 $ 615
 

Southwestern Energy recorded net income attributable to common stock of
$51 million or $0.09 per diluted share. Compared to the second quarter
of 2017, net income attributable to common stock was lower primarily due
to an unrealized marked to market loss (non-cash) on hedging positions
of $56 million in 2018 compared to a $173 million gain in 2017.

Adjusted net income attributable to common stock was $105 million, or
$0.18 per diluted share for the second quarter of 2018 and adjusted
earnings before interest, taxes and amortization ("adjusted EBITDA") was
$317 million, a 13% increase compared to the second quarter of 2017. The
primary components of adjusted EBITDA included $195 million from
Appalachia operations, $56 million from Fayetteville operations, and $45
million from Midstream operations. The increase in adjusted EBITDA was
primarily due to a 44% increase in liquids production along with
stronger realized oil and NGL pricing and a 1% increase in gas
production, partially offset by lower natural gas prices.

Weighted average realized pricing, including derivatives, transportation
and the benefit of higher NGL and oil pricing, was $2.30 per Mcfe
compared to a NYMEX gas price of $2.80 per Mcf. The Company was able to
mitigate the effect of a $0.38 per Mcf lower NYMEX gas price compared to
the same period in 2017 through improvement in differentials, growth in
liquids pricing and production, along with a realized hedge gain of
$0.09 per Mcfe in 2018.

At June 30, 2018, the Company had liquidity of $1.5 billion and debt of
$3.6 billion. During the quarter, the Company's credit ratings were
upgraded one notch by S&P and Moody's to BB and Ba2, respectively.

Southwestern Energy continues to execute a disciplined hedging program
with physical, financial and basis hedges on its forecasted natural gas,
natural gas liquids and oil production. In line with the Company's focus
on increased liquids exposure, the majority of hedging activity during
the quarter was focused on ethane and propane fixed price swaps. A
summary of the Company's financial hedging position is provided in the
attached financial tables. Additional information on physical
derivatives, natural gas liquids and oil financial derivatives can be
found in the 10-Q.

E&P Operational Review

Improvement in operational cycle times, increased gathering capacity and
stronger well results drove higher net production volumes of 234 Bcfe,
including 5,585 MBbls, or 61,370 barrels per day, from natural gas
liquids and condensate. Liquids production exceeded the top end of
guidance by 9%. Appalachia Basin production totaled 167 Bcfe, a 19%
increase. The Company invested $396 million in E&P capital and drilled
37 wells, completed 56 wells and placed 45 wells to sales.

               
OPERATING STATISTICS For the three months ended For the six months ended
June 30, June 30,
2018 2017 2018 2017
Production
Gas production (Bcf) 201 199 398 382
Oil production (MBbls) 723 565 1,336 1,084
NGL production (MBbls) 4,862 3,316 9,092 6,324
Total production (Bcfe) 234 222 460 426
 
Division Production
Northeast Appalachia (Bcf) 112 97 220 184
Southwest Appalachia (Bcfe) 55 43 106 79
Fayetteville Shale (Bcf) 67 82 134 163
 
Average unit costs per Mcfe
Lease operating expenses $ 0.91 $ 0.89 $ 0.93 $ 0.89
General & administrative expenses(1) $ 0.19 $ 0.23 $ 0.20 $ 0.22
Taxes, other than income taxes(2,3) $ 0.06 $ 0.10 $ 0.07 $ 0.11
Full cost pool amortization $ 0.50 $ 0.44 $ 0.49 $ 0.42
    (1)   Excludes $15 million of restructuring charges and $7.9 million of
legal settlement charges for the three and six months ended June 30,
2018.

(2)

Excludes $1 million of restructuring charges for the three and six
months ended June 30, 2018.

(3)

Decrease primarily due to an $8 million severance tax refund
related to a favorable assessment on deductible expenses in
Southwest Appalachia for the three and six months ended June 30,
2018.

 
               
 
COMMODITY PRICES For the three months ended For the six months ended
June 30, June 30,
2018 2017 2018 2017
Natural Gas Price:
NYMEX Henry Hub Price ($/MMBtu) (1) $ 2.80 $ 3.18 $ 2.90 $ 3.25
Discount to NYMEX (2) (0.81 ) (0.83 ) (0.55 ) (0.72 )
Average realized gas price per Mcf, excluding derivatives $ 1.99 $ 2.35 $ 2.35 $ 2.53
Gain (loss) on settled financial basis derivatives ($/Mcf) (0.01 ) (0.15 ) (0.06 ) (0.08 )
Gain (loss) on settled commodity derivatives ($/Mcf) 0.13 (0.05 ) 0.10 (0.10 )
Average realized gas price per Mcf, including derivatives $ 2.11 $ 2.15 $ 2.39 $ 2.35
Oil Price:
WTI oil price ($/Bbl) $ 67.88 $ 48.28 $ 65.37 $ 50.10
Discount to WTI (7.73 ) (7.72 ) (7.12 ) (8.02 )
Average oil price per Bbl, excluding derivatives $ 60.15 $ 40.56 $ 58.25 $ 42.08
Average oil price per Bbl, including derivatives $ 59.22 $ 40.56 $ 57.74 $ 42.08
NGL Price:
Average net realized NGL price per Bbl, excluding derivatives $ 15.37 $ 11.21 $ 15.39 $ 12.19
Average net realized NGL price per Bbl, including derivatives $ 15.05 $ 11.25 $ 15.22 $ 12.22
Percentage of WTI 23 % 23 % 24 % 24 %
Average net realized C3+ price per Bbl, excluding derivatives $ 33.11 $ 21.62 $ 34.49 $ 25.68
Average net realized C3+ price per Bbl, including derivatives $ 32.32 $ 21.62 $ 34.07 $ 25.68
Percentage of WTI 49 % 45 % 53 % 51 %
Total Weighted Average Realized Price:
Excluding derivatives ($/Mcfe) $ 2.21 $ 2.37 $ 2.51 $ 2.55
Including derivatives ($/Mcfe) $ 2.30 $ 2.20 $ 2.53 $ 2.39
    (1)   Based on last day monthly futures settlement prices

(2)

This discount includes a basis differential, a heating content
adjustment, physical basis sales, third-party transportation
charges and fuel charges, and excludes financial basis derivatives.

 
           
Three Months Ended June 30, 2018 E&P Division Results Appalachia Fayetteville
Northeast Southwest Shale
Production (Bcfe)(1) 112 55 67
Gross operated production as of June 2018 (MMcfe/d) 1,563 992 1,065
Net operated production as of June 2018 (MMcfe/d) 1,304 615 705
 
Capital investments ($ in millions)
Exploratory and development drilling, including workovers $ 135 $ 168 $ 4
Acquisition and leasehold 3 12
Seismic and other 1 2 2
Capitalized interest and expense   10     38     4  
Total capital investments $ 149 $ 220 $ 10
 
Gross operated well activity summary
Drilled 17 20
Completed 25 30 1
Wells to sales 17 26 2
 
Average completed well cost (in millions) $ 8.2

(2)

$ 8.9 $ 5.6
Average lateral length (in ft) 7,748 7,851 6,793
 
Realized Natural Gas Price
NYMEX Henry Hub Price ($/MMBtu) $ 2.80 $ 2.80 $ 2.80
Discount to NYMEX (3)   (0.90 )   (0.57 )   (0.72 )
Average realized gas price per Mcf, excluding derivatives $ 1.90   $ 2.23   $ 2.08  
Total weighted average realized price per Mcfe, excluding derivatives $ 1.90 $ 3.00 $ 2.08
    (1)   Southwest Appalachia production included 22 Bcf of natural gas,
4,850 MBbls of NGLs and 707 MBbls of oil.

(2)

Average well costs includes amounts for delineation and science.

(3)

This discount includes a basis differential, a heating content
adjustment, physical basis sales, third-party transportation
charges and fuel charges, and excludes financial basis derivatives.

 

Northeast Appalachia – Total net production of 112
Bcf, or 1.2 Bcf per day, was 15% higher than the second quarter of 2017.
The Company placed 17 wells to sales in the second quarter, 11 of which
were online for at least 30 days and utilized the latest completion and
flowback design and had an average 30-day rate of 17.2 MMcf per day.

The Company has expanded its core position in Tioga to 37,500 net acres.
In July, the Company entered into a joint development agreement with a
private firm, adding 23 future drilling locations with projected lateral
lengths averaging 11,000 feet.

The Company is continuing to enhance returns in Tioga, by coupling
additional cost savings with improving well results. In the second
quarter, a three-well pad in Tioga utilized water from the previously
announced water project and benefited from eight completion stages per
day, reducing completion costs by 12% compared to the first development
pad in that area. Eight wells were placed to sales and are outperforming
historical offsets due to operational improvements including optimized
completion designs, targeted drilling zones and the benefit of
field-wide compression. Of note, a two-well pad had an average lateral
length of 7,250 feet and an average 30-day rate of 23.9 MMcf per day,
outperforming the initial Tioga development pad by 49%.

Southwest Appalachia – Total net production was 55
Bcfe, or 604 MMcfe per day, including 60% liquids. Natural gas liquids
and oil production averaged 53,300 and 7,800 barrels per day,
respectively, representing increases of 47% and 31% compared to the
second quarter of 2017.

During the quarter, the Company continued to focus on the rich gas area
in West Virginia, which provides some of the highest margins in the
Company, bringing 26 wells online. Southwest Appalachia's margin in the
second quarter of 2018 was 76% higher, at $1.60 per Mcfe, compared to
the same period in 2017. The margin improvement was primarily driven by
higher liquids production and prices, which provided a $0.77 per Mcfe
uplift in realized pricing. The weighted average realized price was
$3.00 per Mcfe compared to a realized natural gas prices of $2.23 per
Mcf.

The Company's rich gas wells account for approximately 75% of the
Company's drilling efforts in Southwest Appalachia in 2018. Two wells on
a recently developed pad are still producing 1,500 barrels of condensate
per day after 90 days of production and are among the highest condensate
producers reported in the Basin.

The Company continues to realize the benefits of improving capital
efficiencies as evidenced by a three-well pad that was drilled and
completed at approximately $940 per foot. The pad benefited from
increased completion stages pumped per day and reduced cycle times,
which decreased costs and accelerated production. The three wells
averaged an extended lateral length of over 10,700 feet and proppant
loading of 2,500 pounds per foot with an average cost of $10.1 million
per well.

Fayetteville Shale – During the second quarter of 2018,
the Company produced 67 Bcf of natural gas from the Fayetteville Shale,
compared to 82 Bcf in the second quarter of 2017, while generating
positive net cash provided by operating activities, net of capital
investments, of $78 million for its E&P and midstream business.

The Company placed two redevelopment wells online in mid-April, which
utilize advanced completion designs and optimized landing zones. These
wells have been online over 90 days, and in addition the initial
redevelopment well has been online over 275 days. All of these wells
continue to outperform offset well EURs by 25% to 50%. In addition, the
Company is continuing to focus on its base production optimization
efforts to manage the impact of natural decline.

Conference Call

Southwestern management will host a conference call and webcast on
Friday, August 3, 2018 at 9:00 a.m. Central to discuss second quarter
2018 results. To participate, dial US toll-free 877-883-0383, or
international 412-902-6505 and enter access code 6510656. The conference
call will webcast live at www.swn.com.

Southwestern Energy Company is an independent energy company whose
wholly-owned subsidiaries are engaged in natural gas and oil
exploration, development and production, natural gas gathering and
marketing. Additional information on the Company can be found on our
website: www.swn.com

This news release contains forward-looking statements. Forward-looking
statements relate to future events and anticipated results of
operations, business strategies, and other aspects of our operations or
operating results. In many cases you can identify forward-looking
statements by terminology such as "anticipate," "intend," "plan,"
"project," "estimate," "continue," "potential," "should," "could,"
"may," "will," "objective," "guidance," "outlook," "effort," "expect,"
"believe," "predict," "budget," "projection," "goal," "forecast,"
"target" or similar words. Statements may be forward looking even in the
absence of these particular words. Where, in any forward-looking
statement, the Company expresses an expectation or belief as to future
results, such expectation or belief is expressed in good faith and
believed to have a reasonable basis. However, there can be no assurance
that such expectation or belief will result or be achieved. The actual
results of operations can and will be affected by a variety of risks and
other matters including, but not limited to, changes in commodity
prices; changes in expected levels of natural gas and oil reserves or
production, or the execution or realization of any specific strategic
alternative, which the Company has previously announced it is exploring
for its Fayetteville Shale assets; operating hazards, drilling risks,
unsuccessful exploratory activities; limited access to capital or
significantly higher cost of capital related to illiquidity or
uncertainty in the domestic or international financial markets;
international monetary conditions; unexpected cost increases; potential
liability for remedial actions under existing or future environmental
regulations; potential liability resulting from pending or future
litigation; and general domestic and international economic and
political conditions; as well as changes in tax, environmental and other
laws applicable to our business. Other factors that could cause actual
results to differ materially from those described in the forward-looking
statements include other economic, business, competitive and/or
regulatory factors affecting our business generally as set forth in our
filings with the Securities and Exchange Commission. Unless legally
required, Southwestern Energy Company undertakes no obligation to update
publicly any forward-looking statements, whether as a result of new
information, future events or otherwise.

 
SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
    For the three months ended     For the six months ended
June 30, June 30,
2018     2017 2018     2017
(in millions, except share/per share amounts)
Operating Revenues
Gas sales $ 407 $ 471 $ 947 $ 974
Oil sales 44 23 79 46
NGL sales 75 37 140 77
Marketing 265 250 518 503
Gas gathering 24 30 48 57
Other   1         4      
  816     811     1,736     1,657  
Operating Costs and Expenses
Marketing purchases 265 253 520 504
Operating expenses 193 164 382 311
General and administrative expenses 59 58 114 108
Restructuring charges 18 18
Depreciation, depletion and amortization 142 123 285 229
Taxes, other than income taxes   15     25     38     51  
  692     623     1,357     1,203  
Operating Income   124     188     379     454  
Interest Expense
Interest on debt 59 59 124 117
Other interest charges 2 3 4 5
Interest capitalized   (29 )   (28 )   (57 )   (56 )
32 34 71 66
 
Gain (Loss) on Derivatives (1) (36 ) 134 (43 ) 250
Loss on Early Extinguishment of Debt (8 ) (10 ) (8 ) (11 )
Other Income, Net   3     6     2     8  
 
Income Before Income Taxes 51 284 259 635
Provision (Benefit) for Income Taxes
Deferred                
               
Net Income $ 51   $ 284   $ 259   $ 635  
Mandatory convertible preferred stock dividend 27 54
Participating securities - mandatory convertible preferred stock       33     2     76  
Net Income Attributable to Common Stock $ 51   $ 224   $ 257   $ 505  
 
Income Per Common Share
Basic $ 0.09   $ 0.45   $ 0.45   $ 1.02  
Diluted $ 0.09   $ 0.45   $ 0.44   $ 1.02  
Weighted Average Common Shares Outstanding
Basic

 

 

 

581,159,200

    496,419,815     576,255,744     494,753,391  
Diluted

 

 

 

582,878,106

    498,224,599     578,222,740     496,627,843  
 
       
SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
June 30, December 31,
2018 2017
ASSETS (in millions)
Current assets:
Cash and cash equivalents $ 37 $ 916
Accounts receivable, net 416 428
Derivative assets 71 130
Other current assets   43     35  
Total current assets 567 1,509
Natural gas and oil properties, using the full cost method,
including $1,835 million as of June 30, 2018 and $1,817 million as
of December 31, 2017 excluded from amortization
24,611 23,890
Gathering systems 1,322 1,315
Other 576 564
Less: Accumulated depreciation, depletion and amortization   (20,276 )   (19,997 )
Total property and equipment, net 6,233 5,772
Other long-term assets   242     240  
TOTAL ASSETS $ 7,042   $ 7,521  
 
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable $ 642 $ 533
Taxes payable 58 62
Interest payable 68 70
Dividends payable 27
Derivative liabilities 66 64
Other current liabilities   24     24  
Total current liabilities 858 780
Long-term debt 3,570 4,391
Pension and other postretirement liabilities 55 58
Other long-term liabilities   309     313  
Total long-term liabilities 3,934 4,762
Equity:
Common stock, $0.01 par value; 1,250,000,000 shares authorized;
issued 586,430,101 shares as of June 30, 2018 and 512,134,311 as of
December 31, 2017
6 5
Preferred stock, $0.01 par value, 10,000,000 shares authorized,
6.25% Series B Mandatory Convertible, $1,000 per share liquidation
preference, 1,725,000 shares issued and outstanding as of December
31, 2017, converted to common stock on January 12, 2018
Additional paid-in capital 4,709 4,698
Accumulated deficit (2,420 ) (2,679 )
Accumulated other comprehensive loss (44 ) (44 )
Common stock in treasury; 31,269 shares as of June 30, 2018 and
December 31, 2017, respectively
  (1 )   (1 )
Total equity   2,250     1,979  
TOTAL LIABILITIES AND EQUITY $ 7,042   $ 7,521  
 
       
SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
For the six months ended
June 30,
2018 2017
(in millions)
Cash Flows From Operating Activities:
Net income $ 259 $ 635
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation, depletion and amortization 285 229
Amortization of debt issuance costs 4 4
(Gain) loss on derivatives, unsettled 54 (319 )
Stock-based compensation 9 12
Loss on early extinguishment of debt 8 11
Other 1 (4 )
Change in assets and liabilities   44     10  
Net cash provided by operating activities   664     578  
 
Cash Flows From Investing Activities:
Capital investments (684 ) (619 )
Proceeds from sale of property and equipment 6 12
Other   3     1  
Net cash used in investing activities   (675 )   (606 )
 
Cash Flows From Financing Activities:
Payments on long-term debt (1,191 ) (287 )
Payments on revolving credit facility (645 )
Borrowings under revolving credit facility 1,005
Change in bank drafts outstanding 3
Debt issuance costs (9 )
Preferred stock dividend (27 )
Cash paid for tax withholding   (1 )    
Net cash used in financing activities   (868 )   (284 )
 
Decrease in cash and cash equivalents (879 ) (312 )
Cash and cash equivalents at beginning of year   916     1,423  
Cash and cash equivalents at end of period $ 37   $ 1,111  
 
 
SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
SEGMENT INFORMATION
(Unaudited)
    Exploration                
and Midstream
Production Services Other Eliminations Total
(in millions)

Three months ended June 30, 2018

Revenues $ 520 $ 797 $ $ (501 ) $ 816
Marketing purchases 716 (451 ) 265
Operating expenses 215 28 (50 ) 193
General and administrative expenses 53

(1)

6 59
Restructuring charges 16 2 18
Depreciation, depletion and amortization 126 16 142
Taxes, other than income taxes 13 2 15
Operating income 97 27 124
Capital investments (2) 396 5 2 403
 

Three months ended June 30, 2017

Revenues $ 526 $ 822 $ $ (537 ) $ 811
Marketing purchases 731 (478 ) 253
Operating expenses 200 23 (59 ) 164
General and administrative expenses 50 8 58
Depreciation, depletion and amortization 107 16 123
Taxes, other than income taxes 23 2 25
Operating income 146 42 188
Capital investments (2) 318 6 1 325
 

Six months ended June 30, 2018

Revenues $ 1,157 $ 1,693 $ $ (1,114 ) $ 1,736
Marketing purchases 1,535 (1,015 ) 520
Operating expenses 428 53 (99 ) 382
General and administrative expenses 101

(1)

13 114
Restructuring charges 16 2 18
Depreciation, depletion and amortization 243 42

(3)

285
Taxes, other than income taxes 34 4 38
Operating income 335 44 379
Capital investments (2) 730 9 2 741
 

Six months ended June 30, 2017

Revenues $ 1,089 $ 1,680 $ $ (1,112 ) $ 1,657
Marketing purchases 1,496 (992 ) 504
Operating expenses 381 50 (120 ) 311
General and administrative expenses 93 15 108
Depreciation, depletion and amortization 197 32 229
Taxes, other than income taxes 47 4 51
Operating income 371 83 454
Capital investments (2) 601 12 2 615
    (1)   Includes $7.9 million of legal settlement charges.

(2)

Capital investments include increases of $19 million and $41
million for the three months ended June 30, 2018 and 2017,
respectively, and an increase of $52 million and a decrease of $11
million for the six months ended June 30, 2018 and 2017,
respectively, relating to the change in capital accruals between
periods.

(3)

Includes a $10 million impairment related to certain non-core
gathering assets.

 

Hedging Summary

A detailed breakdown of the Company's natural gas derivative financial
instruments and financial basis positions as of July 31, 2018 is shown
below. Please refer to our quarterly report on Form 10-Q to be filed
with the Securities and Exchange Commission for complete information on
the Company's commodity, basis and interest rate protection.

                   
Financial protection on production Weighted Average Price per MMBtu
Volume Sold Purchased Sold
(Bcf) Swaps Puts Puts Calls
Natural Gas

2018

Sold fixed price swaps 156 $ 2.96 $ $ $
Two-way costless collars 6 2.90 3.27
Three-way costless collars 143 2.40 2.97 3.37

Total

305

2019

Sold fixed price swaps 147 $ 2.93 $ $ $
Two-way costless collars 53 2.80 2.98
Three-way costless collars 133 2.49 2.93 3.34

Total

333

2020

Sold fixed price swaps 2 $ 2.77 $ $ $
Three-way costless collars 47 2.43 2.80 3.09
Total 49
 
       
Other Derivative Contracts Weighted Average
Volume Strick Price per
(Bcf) MMBtu
Purchased Call Options - Natural Gas

   2020

68 $ 3.63

   2021

57 3.52
Total 125
 
Sold Call Options - Natural Gas

   2018

31 $ 3.50

   2019

52 3.50

   2020

137 3.39

   2021

114 3.33
Total 334
 
       

 

Financial basis positions Volume

Basis Differential

(excludes physical positions) (Bcf)     ($/MMBTU)
 
Q3 2018
Dominion South 16.8 $ (0.65 )
TETCO M3 11.5   (0.51 )
Total 28.3 $ (0.60 )
 
2018
Dominion South 26.6 $ (0.65 )
TETCO M3 17.8   (0.48 )
Total 44.4 $ (0.58 )
 
2019
Dominion South 1.0 $ (0.63 )
TETCO M3 9.7   1.44  
Total 10.7 $ 1.24

Note: 2018 includes Q3 2018 positions

 

Explanation and Reconciliation of Non-GAAP
Financial Measures

The Company reports its financial results in accordance with accounting
principles generally accepted in the United States of America ("GAAP").
However, management believes certain non-GAAP performance measures may
provide financial statement users with additional meaningful comparisons
between current results, the results of its peers and of prior periods.

One such non-GAAP financial measure is net cash flow. Management
presents this measure because (i) it is accepted as an indicator of an
oil and gas exploration and production company's ability to internally
fund exploration and development activities and to service or incur
additional debt, (ii) changes in operating assets and liabilities relate
to the timing of cash receipts and disbursements which the Company may
not control and (iii) changes in operating assets and liabilities may
not relate to the period in which the operating activities occurred.

Additional non-GAAP financial measures the Company may present from time
to time are net debt, adjusted net income, adjusted diluted earnings per
share, adjusted EBITDA and its E&P and Midstream segment operating
income, all which exclude certain charges or amounts. Management
presents these measures because (i) they are consistent with the manner
in which the Company's position and performance are measured relative to
the position and performance of its peers, (ii) these measures are more
comparable to earnings estimates provided by securities analysts, and
(iii) charges or amounts excluded cannot be reasonably estimated and
guidance provided by the Company excludes information regarding these
types of items. These adjusted amounts are not a measure of financial
performance under GAAP.

See the reconciliations throughout this release of GAAP financial
measures to non-GAAP financial measures for the three and six months
ended June 30, 2018 and June 30, 2017, as applicable. Non-GAAP financial
measures should not be considered in isolation or as a substitute for
the Company's reported results prepared in accordance with GAAP.

       
3 Months Ended June 30,
2018 2017
(in millions)
Net income attributable to common stock:
Net income attributable to common stock $ 51 $ 224
Add back:
Participating securities – mandatory convertible preferred stock 27
Restructuring charges 18
(Gain) loss on certain derivatives 56 (173 )
Gain on sale of assets, net (2 )
Loss on early extinguishment of debt 8 10
Legal settlement charges 8
Adjustments due to inventory valuation and other (1 ) (1 )
Adjustments due to discrete tax items(1) (13 ) (108 )
Tax impact on adjustments   (22 )   63  
Adjusted net income attributable to common stock $ 105   $ 40  
    (1)   Primarily relates to the exclusion of certain discrete tax
adjustments associated with the valuation allowance against deferred
tax assets. The Company expects its 2018 income tax rate to be 24.5%
before the impacts of any valuation allowance.
 
       
 
6 Months Ended June 30,
2018 2017
(in millions)
Net income attributable to common stock:
Net income attributable to common stock $ 257 $ 505
Add back:
Participating securities – mandatory convertible preferred stock 57
Impairment of non-core gathering assets 10
Restructuring charges 18
(Gain) loss on certain derivatives 54 (319 )
Gain on sale of assets, net (1 ) (3 )
Loss on early extinguishment of debt 8 11
Legal settlement charges 8
Adjustments due to inventory valuation and other 2 (1 )
Adjustments due to discrete tax items(1) (64 ) (242 )
Tax impact on adjustments   (25 )   119  
Adjusted net income attributable to common stock $ 267   $ 127  
    (1)   Primarily relates to the exclusion of certain discrete tax
adjustments associated with the valuation allowance against deferred
tax assets. The Company expects its 2018 income tax rate to be 24.5%
before the impacts of any valuation allowance.
 
       
3 Months Ended June 30,
2018 2017
Diluted earnings per share:
Diluted earnings per share $ 0.09 $ 0.45
Add back:
Participating securities - mandatory convertible preferred stock 0.06
Restructuring charges 0.03
(Gain) loss on certain derivatives 0.10 (0.36 )
Gain on sale of assets, net (0.00 )
Loss on early extinguishment of debt 0.01 0.02
Legal settlement charges 0.01
Adjustments due to inventory valuation and other (0.00 ) (0.00 )
Adjustments due to discrete tax items(1) (0.02 ) (0.22 )
Tax impact on adjustments   (0.04 )   0.13  
Adjusted diluted earnings per share $ 0.18   $ 0.08  
    (1)   Primarily relates to the exclusion of certain discrete tax
adjustments associated with the valuation allowance against deferred
tax assets. The Company expects its 2018 income tax rate to be 24.5%
before the impacts of any valuation allowance.
 
       
6 Months Ended June 30,
2018 2017
Diluted earnings per share:
Diluted earnings per share $ 0.44 $ 1.02
Add back:
Participating securities - mandatory convertible preferred stock 0.11
Impairment of non-core gathering assets 0.02
Restructuring charges 0.03
(Gain) loss on certain derivatives 0.09 (0.64 )
Gain on sale of assets, net (0.00 ) (0.00 )
Loss on early extinguishment of debt 0.02 0.02
Legal settlement charges 0.01
Adjustments due to inventory valuation and other 0.00 (0.00 )
Adjustments due to discrete tax items(1) (0.11 ) (0.49 )
Tax impact on adjustments   (0.04 )   0.24  
Adjusted diluted earnings per share $ 0.46   $ 0.26  
    (1)   Primarily relates to the exclusion of certain discrete tax
adjustments associated with the valuation allowance against deferred
tax assets. The Company expects its 2018 income tax rate to be 24.5%
before the impacts of any valuation allowance.
 
       
3 Months Ended June 30,
2018 2017
(in millions)
Net cash flow provided by operating activities:
Net cash provided by operating activities $ 300 $ 266
Add back:
Changes in operating assets and liabilities (38 ) (16 )
Restructuring charges   18      
Net Cash Flow $ 280   $ 250  
 
6 Months Ended June 30,
2018 2017
(in millions)
Net cash provided by operating activities:
Net cash provided by operating activities $ 664 $ 578
Add back:
Changes in operating assets and liabilities (44 ) (10 )
Restructuring charges   18      
Net Cash Flow $ 638   $ 568  
 
3 Months Ended June 30,
2018 2017
(in millions)
EBITDA:
Net income $ 51 $ 284
Add back:
Interest expense 32 34
Income tax expense
Depreciation, depletion and amortization 142 123
Restructuring charges 18
Gain on sale of assets, net (2 )
Loss on early extinguishment of debt 8 10
Legal settlement charges 8
(Gain) loss on certain derivatives 56 (173 )
Adjustments due to inventory valuation and other (1 ) (1 )
Stock based compensation expense   3     6  
Adjusted EBITDA $ 317   $ 281  
 
6 Months Ended June 30,
2018 2017
(in millions)
EBITDA:
Net income

$

259 $ 635
Add back:
Interest expense 71 66
Income tax benefit
Depreciation, depletion and amortization 285 229
Restructuring charges 18
Gain on sale of assets, net (1 ) (3 )
Loss on early extinguishment of debt and other bank fees 8 11
Legal settlement charges 8
(Gain) loss on certain derivatives 54 (319 )
Adjustments due to inventory valuation and other 2 (1 )
Stock based compensation expense   9     13  
Adjusted EBITDA $ 713   $ 631  
 

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